Numerical simulations of CO2 injection into a porous sandstone formation
CO2 is sequestered in geological formations by three trapping mechanisms: solubility, mineral and hydrodynamic trapping. This is to capture and securely storage the CO2 emissions produced by human activities from reaching the atmosphere. For this to happen the injectivity of the formation needs to b...
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| Format: | Conference Paper |
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WITS Press
2012
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| Online Access: | http://hdl.handle.net/20.500.11937/33876 |
| _version_ | 1848754068094189568 |
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| author | Cole, J. Rasouli, Vamegh |
| author2 | Prof Fuad Khoshnaw |
| author_facet | Prof Fuad Khoshnaw Cole, J. Rasouli, Vamegh |
| author_sort | Cole, J. |
| building | Curtin Institutional Repository |
| collection | Online Access |
| description | CO2 is sequestered in geological formations by three trapping mechanisms: solubility, mineral and hydrodynamic trapping. This is to capture and securely storage the CO2 emissions produced by human activities from reaching the atmosphere. For this to happen the injectivity of the formation needs to be evaluated, for which formation permeability and flow properties are important factors to be determined. Also, relative permeability and residual saturation should be estimated when two phase flow is injected, e.g. brine and CO2. In this paper it was attempted to simulate numerically a core flooding lab experiment conducted to investigate injectivity of a sandstone sample. The experiment consisted of primary drainage displacement (brine displaced by CO2) followed by primary imbibition (CO2 displaced by brine) flood. The production profiles at both injection phases were estimated and the differential pressure across the sample was recorded. ANSYS software was implemented in this study to construct a 3D core sample with similar size to the one tested in the lab. A fine grid mesh was generated for the model. Both injection phases were simulated numerically using the lab data. The pressure drop across the sample and the velocity profiles were extracted. Also, the relative permeability of the two phases was estimated. The results showed a fairly good agreement with those obtained from the lab experiments. The results are presented and interpreted. |
| first_indexed | 2025-11-14T08:34:32Z |
| format | Conference Paper |
| id | curtin-20.500.11937-33876 |
| institution | Curtin University Malaysia |
| institution_category | Local University |
| last_indexed | 2025-11-14T08:34:32Z |
| publishDate | 2012 |
| publisher | WITS Press |
| recordtype | eprints |
| repository_type | Digital Repository |
| spelling | curtin-20.500.11937-338762017-09-13T15:52:28Z Numerical simulations of CO2 injection into a porous sandstone formation Cole, J. Rasouli, Vamegh Prof Fuad Khoshnaw ANSYS relative permeability CFX CO2 modelling CO2 is sequestered in geological formations by three trapping mechanisms: solubility, mineral and hydrodynamic trapping. This is to capture and securely storage the CO2 emissions produced by human activities from reaching the atmosphere. For this to happen the injectivity of the formation needs to be evaluated, for which formation permeability and flow properties are important factors to be determined. Also, relative permeability and residual saturation should be estimated when two phase flow is injected, e.g. brine and CO2. In this paper it was attempted to simulate numerically a core flooding lab experiment conducted to investigate injectivity of a sandstone sample. The experiment consisted of primary drainage displacement (brine displaced by CO2) followed by primary imbibition (CO2 displaced by brine) flood. The production profiles at both injection phases were estimated and the differential pressure across the sample was recorded. ANSYS software was implemented in this study to construct a 3D core sample with similar size to the one tested in the lab. A fine grid mesh was generated for the model. Both injection phases were simulated numerically using the lab data. The pressure drop across the sample and the velocity profiles were extracted. Also, the relative permeability of the two phases was estimated. The results showed a fairly good agreement with those obtained from the lab experiments. The results are presented and interpreted. 2012 Conference Paper http://hdl.handle.net/20.500.11937/33876 10.2495/PMR120061 WITS Press restricted |
| spellingShingle | ANSYS relative permeability CFX CO2 modelling Cole, J. Rasouli, Vamegh Numerical simulations of CO2 injection into a porous sandstone formation |
| title | Numerical simulations of CO2 injection into a porous sandstone formation |
| title_full | Numerical simulations of CO2 injection into a porous sandstone formation |
| title_fullStr | Numerical simulations of CO2 injection into a porous sandstone formation |
| title_full_unstemmed | Numerical simulations of CO2 injection into a porous sandstone formation |
| title_short | Numerical simulations of CO2 injection into a porous sandstone formation |
| title_sort | numerical simulations of co2 injection into a porous sandstone formation |
| topic | ANSYS relative permeability CFX CO2 modelling |
| url | http://hdl.handle.net/20.500.11937/33876 |